Remote drilling and completions management

ABSTRACT

A methodology reduces the needed number of personnel on a rig by enabling performance of a variety of functions from a remote location. The method comprises utilizing a plurality of observation devices which monitor rig parameters remotely. Data from the observation devices is transmitted to a remote operations center used to analyze the data for determining operational changes to the rig. Control instructions may then be transmitted to the rig to implement the operational changes.

CROSS-REFERENCE TO RELATED APPLICATION

The present document is based on and claims priority to U.S. ProvisionalApplication Ser. No. 61/290967, filed Dec. 30, 2009.

BACKGROUND

A variety of subterranean fluids are recovered from undergroundformations through the use of wells drilled into or through theunderground formations. Wells may be used for exploration and productionrelated to a variety of fluids, including oil, gas, water, geothermalfluids and other types of liquids and/or gases. In many applications, arig is employed to facilitate drilling and other well constructionactivities. Traditionally, a relatively large number of rig operatorsand other personnel have been employed on the rig to perform the complexoperations related to construction of the well. However, the requirementof these relatively large numbers at the rig location adds to theexpense and complexity of the operation.

SUMMARY

In general, the present invention provides a methodology for reducingthe number of personnel on a rig. The method comprises utilizing aplurality of observation devices which monitor rig parameters remotely.Data from the observation devices is transmitted to a remote operationscenter, at which the data is analyzed for determining operationalchanges to the rig. Control instructions may then be transmitted to therig to implement the operational changes.

BRIEF DESCRIPTION OF THE DRAWINGS

Certain embodiments of the invention will hereafter be described withreference to the accompanying drawings, wherein like reference numeralsdenote like elements, and:

FIG. 1 is a schematic illustration of a remote operations center incommunication with a rig over a well, according to an embodiment of thepresent invention;

FIG. 2 is a schematic illustration of control systems which may beutilized in the remote operations center and on the rig, according to anembodiment of the present invention;

FIG. 3 is a schematic illustration of a computer-based control systemwhich may be employed in the remote operations center to process dataand/or output operational commands to the rig, according to embodimentof the present invention;

FIG. 4 is a schematic illustration of the control system used on a rigto correspond with the remote operations center and/or to carry out rigrelated operational functions, according to an embodiment of the presentinvention;

FIG. 5 is a schematic illustration of a hierarchy for operationalcontrol of a rig utilizing the remote operations center, according to anembodiment of the present invention; and

FIG. 6 is schematic illustration of a remote operations center,according to an embodiment of the present invention.

DETAILED DESCRIPTION

In the following description, numerous details are set forth to providean understanding of the present invention. However, it will beunderstood by those of ordinary skill in the art that the presentinvention may be practiced without these details and that numerousvariations or modifications from the described embodiments may bepossible.

The present invention generally relates to a methodology which enablesreductions in the number of personnel required on a rig. A plurality ofobservation devices is employed to monitor rig parameters remotely at,for example, a remote operations center. This allows the remoteprocessing of data so that decisions may be made at the remoteoperations center regarding operational changes to the rig. Commands arethen sent to the rig to implement the operational changes. In someembodiments, the collection of data at the rig is performed inreal-time, and the real-time data is automatically transmitted to theremote operations center. The real-time data is then processed todetermine the need for operational changes at the rig. If suchoperational changes are required, command signals may be relayed fromthe remote operations center to initiate automatic changes at the rig.

According to an embodiment of the present invention, the methodology maybe employed generally with respect to hydrocarbon and water explorationand production. By way of example, the methodology and system to carryout the methodology may be employed for remote management of oil, gas,geothermal, and water well construction and recovery operations.

Embodiments of the present invention involve high volume drilling andcompletions activities, with similar well profiles, for enablingconstruction in an efficient manner. Such embodiments comprise new workprocesses and work flows that utilize technology to reduce the number ofpeople required to perform certain tasks, as compared to traditionaloperations. Related patent documents include: U.S. Publication No.US2008-0208475, entitled “Drilling Collaboration Infrastructure,” toSchlumberger Technology Corporation by inventors George Karr, et al;U.S. Publication No. US-2009-0225630, entitled “Data Aggregation ForDrilling Operations,” to Schlumberger Technology Corporation byinventors Shunfeng Zheng. U.S. Publication No. US2008-0208475 and U.S.Publication No. US2009-0225630 are hereby incorporated by reference.

Various embodiments of the present invention include new ways ofconstructing wells (for oil, gas, geothermal, water) with the mainsupervision of such well construction located in a remote site, insteadof the rig itself. This new process utilizes new technology enablers inthe areas of telecommunications, data acquisition and softwaretechnology, and facilitates efficiency improvements in well constructionoperations based on:

improved collaboration,

reduced man-power requirements, and

focused decision making processes.

In remote well drilling and completions management, the rig is animportant component, because all physical operations happen at the rig.The rig comprises a crew of personnel for facilitating rig-basedoperations. An embodiment of the present invention includes a processhaving the steps of taking real-time digital measurements of importantparameters on the rig (for example, through the use of sensors and/orvideo cameras, microphones, video-conference equipment, and so forth)and sending such measurements to a remotely located operations center,which may have an expert and/or management team. This remote operationscenter is in charge of receiving the real-time data, analyzing it,interpreting it, and making informed decisions based on suchinterpretations. In many applications, processing and analysis isperformed automatically on, for example, a computer-based processor toenable decisions regarding rig operational changes. Those decisions arethen communicated back to the rig crew personnel—which is reduced innumber due to the role of the remote operations center—for execution. Asdescribed below, the implementation of those decisions may be automatedand executed via a control system at the rig.

Examples of some of the systems/tasks which may be automated accordingto the methodology described herein include: downlink-to-rotarysteerable systems, control over mud pumps, control over weight on thebit, setting block position, and setting RPMs. Over time, rigs willbecome more and more automated, allowing for more machine-automatedexecution, hence reducing the personnel requirements on the rig evenmore. Still the concepts of embodiments of the present invention willremain the same, because the execution can be done by a machine, aperson(s), or a combination of both.

In embodiments of the present invention described below, partiesinvolved in the remote well management process may include, but are notlimited to:

Well Site Supervisor (Company Man),

Directional Drilling Personnel,

Measurement-While-Drilling Personnel,

Optimization Engineer(s),

Well Engineer(s),

Drilling Engineer(s),

Drilling Superintendent,

Mud representative(s),

Rig representative(s),

Information Technology expert(s),

Software expert(s), and

Completions Personnel.

Other parties are optional and may include: Wireline personnel,Cementing personnel, Fracturing personnel, Coil Tubing personnel, andTesting personnel.

Referring generally to FIG. 1, a schematic illustration is provided of aremote operations center 20 in communication with a rig 22 positionedover a well 24 which may be defined by one or more wellbores 26. In thisembodiment, the remote operations center 20 may be located a substantialdistance from rig 22, and may be positioned at a headquarters or at avariety of other locations around the world. Communications between therig 22 and the remote operations center 20 are represented by line 28,and those communications may be via hard wire, e.g. land lines,wireless, or combinations of hard wired and wireless communicationsystems. By way of example, wireless, satellite-based communications maybe applied to transmit data from rig 22 to remote operations center 20and/or from remote operations center 20 to rig 22.

As illustrated in FIG. 2, both the remote operations center 20 and therig 22 comprise signal transmitters 30, 32, respectively, to transmitsignals therebetween. The specific type of signal transmitter 30, 32depends on the form of communication/communication lines 28 employed todeliver data from rig 22 to remote operations center 20 and/or todeliver control signals from remote operations center 20 to rig 22. Inthis example, signal transmitter 30 further cooperates with a controlsystem 34 which may be a computer-based control system located at remoteoperations center 20. The signal transmitter 32 may be coupled intocooperation with a corresponding control system 36 located on rig 22.The remote control system 34 is used to receive and process data fromrig 22. The processing of data may be accomplished solely on controlsystem 34, or the processing may be accomplished in cooperation withexperts and other personnel at remote operations center 20. The rigcontrol system 36 is employed to collect and facilitate transmission ofdata to remote operations center 20, but the control system 36 also maybe employed for carrying out commands regarding operational changes onthe rig 22.

According to one embodiment, control system 36 is used to obtainreal-time digital measurements of parameters on rig 22. The controlsystem 36 in cooperation with signal transmitter 32 is further employedto automatically transmit the real-time digital measurements to theremote operations center 20 for processing. Once the data is processedand/or further analyzed at remote operations center 20, a determinationis made as to whether rig operational changes are required. If sorequired, command data related to the operational changes is transmittedback to rig 22 via control system 34 in cooperation with signaltransmitter 30. These rig operational changes are then implemented atthe rig 22 by, for example, automated actions, e.g. utilizingdownlink-to-rotary steerable systems, controlling mud pumps, controllingweight on the bit, setting block position, automatically adjusting atoolface position of a downhole motor, automatically adjusting atoolface position of a downhole turbine, automatically adjustingproperties, e.g. viscosity, density, fluid loss, and/or otherproperties, of drilling mud and/or completions mud, and changing drillstring RPMs.

In the embodiment illustrated in FIG. 2, the acquisition of data, e.g.the acquisition of real-time digital measurements of rig parameters, maybe accomplished with a variety of different types of observation devices38. By way of example, observation devices 38 may comprise one or morevideo cameras 40, microphones 42 or sensors 44. In the exampleillustrated, video cameras 40, microphones 42, and sensors 44 arelocated above the surface on rig 22. However, a variety of observationdevices 38 also may be located downhole in wellbore 26. Depending on thespecific application, a variety of downhole sensors 46 or otherobservation devices may be deployed on or in cooperation with varioustypes of downhole equipment 48. In one example, downhole equipment 48comprises a bottom hole assembly 50 having a drilling system forrotating a drill bit 52 in a wellbore drilling operation. Asillustrated, the bottom hole assembly 50 may be deployed downhole by asuitable conveyance 54, such as drill string, extending down from therig 22 positioned at a surface location 56.

The data collected by the various observation devices 38 is relayed tocontrol system 36 via appropriate communication lines 58 which may bewired or wireless communication lines. In this example, the data isaccumulated in real-time via control system 36 and, in cooperation withsignal transmitter 32, is transmitted to remote operations center 20.The rig parameters observed and the type of observation devices 38employed can vary depending on the specific operation, e.g. drillingoperation or other service operation, carried out at rig 22.

Depending on the specific systems and methodology employed, controlsystem 34 and control system 36 may be constructed according to avariety of configurations. According to one example, control system 34comprises a computer-based control system 60, as illustrated in FIG. 3.In at least some applications, the computer-based control system 60 isan automated system programmed to process and evaluate data receivedfrom rig 22 and to automatically transmit command data back to the rigto implement rig operational changes. The computer-based control system60 may comprise a central processing unit (CPU) 62 which is coupled withrig control system 36 via signal transmitters 30, 32 and communicationsystem/lines 28. Additionally, computer-based control system 60 maycomprise a memory 64, an input device 66, and an output device 68.

Input device 66 may comprise a variety of devices, such as a keyboard,mouse, voice recognition unit, touchscreen, other input devices, orcombinations of such devices. Output device 68 may comprise a visualand/or audio output device, such as a monitor having a graphical userinterface 69. Input device 66 and output device 68 may compriseindividual or multiple devices which may be used to facilitateinteraction with experts or other personnel located at the remoteoperations center 20. Additionally, the processing may be done on asingle device or multiple devices located at the remote operationscenter 20. For example, control system 34 may comprise a plurality ofcomputer-based control systems 60 which are networked together orotherwise combined to facilitate remote processing and analysis of dataon a variety of rig parameters.

Rig control system 36 similarly may comprise a variety of controlsystems in the form of individual control devices or plural controldevices which function in cooperation. In the embodiment illustrated inFIG. 4, rig control system 36 is a computer based processing systemdesigned to intake data on rig parameters from the various observationdevices 38, such as video cameras, microphones, surface sensors,downhole sensors, and other devices designed to detect/measure desiredparameters related to the operation of rig 22. Additionally, rig controlsystem 36 may be designed to receive control commands from the remoteoperations center 20 via its transmitter 32. Various rig operationalchanges may be carried out by rig personnel, but those rig operationalchanges also may be automatically implemented by rig control system 36in many applications. During automated control, rig control system 36communicates with various devices 70 (located on the rig 22 and/orlocated downhole in the well 24) via communication lines 72 which may bewired or wireless communication lines. Examples of automated functionswhich may be carried out by rig control system 36 include utilizingdownlink-to-rotary steerable systems, controlling mud pumps, controllingweight on the bit, setting block position, automatically adjusting atoolface position of a downhole motor, automatically adjusting atoolface position of a downhole turbine, automatically adjustingproperties, e.g. viscosity, density, fluid loss, and/or otherproperties, of drilling mud and/or completions mud, and changing drillstring RPMs.

As described above, the ability to readily communicate data between rig22 and remote operations center 20 facilitates an improved control overimplementation of a given rig operation. Additionally, the ability toperform processing and analysis at the remote operations center 20reduces the number of people that would otherwise be employed on the rig22. By implementing the methodology described herein, a relatively smallnumber of personnel may be deployed on rig 22, while other personnel arelocated at a more convenient location, i.e. at the remote operationscenter 20. The combination of automated processing and handling of datacombined with the reduced number of rig personnel provides for moreefficient and enhanced drilling operations and other rig-basedoperations.

The particular arrangement of personnel on rig 22 and at remoteoperations center 20 can vary substantially from one application toanother. Regardless, the present methodology enables cooperation betweena variety of participants without requiring the presence of thoseparticipants at the rig 22. Referring generally to FIG. 5, an example ofthe interaction of rig personnel and remote operations center personnelto achieve a more efficient rig operation is illustrated.

In the example illustrated, both a drilling supervisor 74 and a rigsuperintendent 76 may communicate with each other, observe data, provideinstructions, and interact with other systems and personnel on rig 22and at remote operations center 20. For example, communications may beestablished with factory drilling supervisors 78 and with drillingsupervisors 80 at one or both locations. Consequently, each factorydrilling supervisor 78 or drilling supervisor 80 is better able toprovide input to and receive input from other personnel, includingcompany personnel 82, drilling crew personnel 84, and other personsand/or equipment at remote operations center 20 and/or rig 22. Forexample, the system and methodology enable easy person to person accessand interaction with the control systems 34, 36, e.g. data servers. Theinteraction between persons/equipment also may include interaction withassistant drilling supervisors 86, with regional support centers, withrig safety coordinators 88, and with cooperating third parties 90.

The staff at remote operations center 20 may vary in number andresponsibility according to the specific rig operation carried out viarig 22. As represented schematically in FIG. 6, examples of functionalpersonnel stationed at remote operations center 20 to interact withcontrol system 34 may include a directional driller 92 and factorydrilling supervisor 78. Other examples of possible personnel stationedat remote operations center 20 include an optimization engineer 96 and awell engineer 98. Each person may have access to control system 34 viaappropriate input devices 66 and output devices 68. The variouspersonnel may monitor data received from the observation devices 38 atthe rig site, and they may provide input to improve the manual and/orautomated control over rig 22. For example, programming adjustments maybe made to adjust the automatic control over rig operational changes inresponse to data received from observational devices 38. The personnelat remote operations center 20 also may perform a variety of additionalfunctions related to monitoring of the rig operation, adjusting the rigoperation, communicating information to other interested parties (seeFIG. 5), and carrying out rig operational functions previously conductedby persons stationed on the rig.

As discussed above, the methodology and systems are employed to simplifycontrol over rig operations with reduced rig personnel. The methodologymay be implemented for a variety of rig operations, including drillingoperations, which utilize many types of downhole tools and equipment.Several types of bottom hole assemblies and/or other drilling equipmentand servicing equipment may be controlled downhole via input from rigpersonnel and/or remotely located personnel. Additionally, the numberand type of observation devices, including downhole sensors, surfacesensors, video monitoring equipment, audio equipment, and other types ofobservation devices may be employed to obtain data for processing andanalysis at the remote operations center. The data may be processed andanalyzed by different types of processing systems according to desiredprograms and algorithms alone or in combination with input frompersonnel at the remote operations center. Various levels of automatedcontrol also may be exercised over rig operational changes via controlsystems located at the remote operations center and/or at the rig.

Accordingly, although only a few embodiments of the present inventionhave been described in detail above, those of ordinary skill in the artwill readily appreciate that many modifications are possible withoutmaterially departing from the teachings of this invention. Suchmodifications are intended to be included within the scope of thisinvention as defined in the claims.

1. A method for constructing a well, comprising: obtaining real-timedigital measurements of parameters on a rig; automatically transmittingthe real-time digital measurements to a remote operations center;processing the real-time digital measurements at the remote operationscenter to determine rig operational changes; transmitting data on therigged operational changes back to the rig; and implementing the rigoperational changes.
 2. The method as recited in claim 1, whereinobtaining comprises utilizing sensors mounted on the rig.
 3. The methodas recited in claim 1, wherein obtaining comprises utilizing cameraslocated on the rig.
 4. The method as recited in claim 1, whereinobtaining comprises utilizing microphones located on the rig.
 5. Themethod as recited in claim 1, wherein implementing comprisesautomatically adjusting a rotary steerable system via adownlink-to-rotary steerable system.
 6. The method as recited in claim1, wherein implementing comprises automatically adjusting the operationof a mud pump.
 7. The method as recited in claim 1, wherein implementingcomprises automatically adjusting the weight on a drill bit.
 8. Themethod as recited in claim 1, wherein implementing comprisesautomatically adjusting a block position on the rig.
 9. The method asrecited in claim 1, wherein implementing comprises automaticallyadjusting the RPM of a drilling system.
 10. The method as recited inclaim 1, wherein implementing comprises automatically adjusting atoolface position of a downhole motor.
 11. The method as recited inclaim 1, wherein implementing comprises automatically adjusting atoolface position of a downhole turbine.
 12. The method as recited inclaim 1, wherein implementing comprises automatically adjusting fluidproperties of a mud fluid.
 13. A method for constructing a well,comprising: monitoring rig parameters via a plurality of different typesof observation devices; sending data on the rig parameters to aprocessing system at a remote operations center; processing andanalyzing the data at the remote operations center; and controlling rigoperational changes from the remote operations center based on resultsobtained from processing and analyzing the data.
 14. The method asrecited in claim 13, wherein monitoring comprises obtaining real-timedigital measurements.
 15. The method as recited in claim 14, whereinsending comprises automatically sending real-time digital measurementdata to the remote operations center.
 16. The method as recited in claim13, wherein processing and analyzing comprises processing and analyzingthe data on a computer-based processing system and outputting results toa graphical user interface.
 17. The method as recited in claim 16,wherein controlling comprises utilizing the computer-based processingsystem and the remote operations center to automatically control the rigoperational changes.
 18. A method for efficient well construction,comprising: reducing the number of personnel on a rig; utilizing aplurality of observation devices to monitor rig parameters remotely;making decisions regarding operational changes to the rig at a remoteoperations center; and implementing the operational changes from theremote operations center.
 19. The method as recited in claim 18, whereinmaking decisions comprises processing data from the observation deviceson a computer-based processing system located at the remote operationscenter.
 20. The method as recited in claim 18, wherein implementingcomprises automatically changing a plurality of functions on the rig.